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MA Distributed Generation Interconnection
Seminar
October 18, 2018
National Grid, Hopedale Office
The information summarized in this Distributed Generation Interconnection Seminar for the
convenience of customers is current as of October 18, 2018 and neither the slides nor
related recording should be relied on. Customers are responsible for ensuring that they
comply with all DG rules and regulations, including the interconnection tariff.
Agenda
2
15 min Welcome, Opening Remarks Will Kern
30 min Interconnection Process Overview Jeff Crompton, Ariella Cohen
30 min DG and Energy Storage Updates Will Kern
10 min Break
15 min SMART Jed Ferris
45 min ISO-NE and the Interconnection Process Jacques Asselin with ISO-NE
30 min Questions
30 min Meet and Greet with CEI Job Owners
Importance of the Interconnection
Process
Safety of utility workers and general public
No adverse impact to power quality, in terms of:
Islanding
Transient Voltage Conditions
Noise and Harmonics
Frequency
Voltage Level
Machine Reactive Capability
Customers cannot interconnect to the Electric Power System (EPS) without
the Company’s authorization.
Billing implications
4
Simplified Criteria
UL Listed (1741 SA), inverter based systems with power ratings of
15kW or less on a single phase service on a radial feed
UL Listed (1741 SA), inverter based systems with power ratings of
25kW or less on a three phase service on a radial feed.
The Simplified Process does not apply for:
non-listed inverters or other generators (induction / synchronous /
asynchronous)
aggregate generation capacity of listed inverters that exceed the above-
mentioned limits
6
Interconnection Process Steps
Application
Simplified
Conditional Approval (to construct DG system)
Witness Test (completion package)
Authorization to Interconnect
https://www.nationalgridus.com/masselectric/home/energyeff/4_interconnection-process.asp
http://ngridustest/narragansett/home/energyeff/4_interconnection-process.asp
7
Expedited Criteria
Single phase customers with listed single-phase inverter based systems with
power ratings of >15 kW on a radial feed
Three phase customers with listed three-phase inverter based systems with
power ratings of >25kW on a radial feed
Any project that did not pass the Simplified process screens
Non-simplified projects that do not require an impact study
Maximum size and supplemental review is based on review of screens
10
Interconnection Process Steps
Pre-Application (if over 500 kW)
Application
Expedited
Engineering Review
Supplemental Review
Conditional Approval (to construct DG system)
National Grid Construction
Witness Test
Authorization to Interconnect
https://www.nationalgridus.com/masselectric/home/energyeff/4_interconnection-process.asp
http://ngridustest/narragansett/home/energyeff/4_interconnection-process.asp
11
Expedited Review Path
If any screens are not passed, the
Company may require a
Supplemental Review Agreement
before providing an Interconnection
Service Agreement
Key threshold: if aggregate
generation is less than 67% of
minimum load on the feeder.
Other screens review voltage
quality, reliability and safety to
reduce the potential need for
impact studies.
Relay control system must be well
defined to make supplemental review
easier.
Expedited
Eligible Facilities Listed Inverter DG
Acknowledge Receipt of Application (3 days)
Review Application for
Completeness 10 days
Complete Review of All Screens 25 days
Complete Supplemental Review (if
needed) 20 days or Standard Process
Send Executable Agreement 10 days
Total Maximum Days 45/65 days
Construction Schedule By Mutual Agreement
Notice/ Witness Test Within 10 days of receiving CoC or by
mutual agreement
12
Standard Criteria
Applies to:
Projects that require System Impact Study (SIS)
Large-scale DG projects
Generally greater than 500 kW but project specific
DG projects requiring system modifications at the substation level
Non-listed inverters or generators other than PV:
Induction, Synchronous, Asynchronous
Most CHP systems
All projects that do not qualify for the Simplified or Expedited process
14
Interconnection Process Steps
Pre-Application
Application
Standard
Engineering Review
Impact Study/Detailed Study
Conditional Approval (to construct DG system)
National Grid Construction
Witness Test
Authorization to Interconnect
https://www.nationalgridus.com/masselectric/home/energyeff/4_interconnection-process.asp
http://ngridustest/narragansett/home/energyeff/4_interconnection-process.asp
15
Standard Review Path
Impact Study will determine the level of
impact on EPS, other customers, other
generators
Impact and/or Detailed Study will determine
System Modifications required and cost (Risk
of Islanding)
ISO-NE Notification Process and
Transmission Study may be required
Interconnection Service Agreement (ISA)
provided after study completed or an Early
ISA could be requested if Detailed Study is
required
If substation modifications required, Company
has 60 BD for study (MDPU 1320 – pg. 50)
Standard
Eligible Facilities Any DG
Acknowledge Receipt of Application (3 days)
Review Application for Completeness 10 days
Complete Standard Process Initial
Review 20 days
Send Impact Study Agreement 5 days
Complete Impact Study 55 days or 60 Days Complex
Complete Detailed Study (if needed) 30 days or by mutual agreement
Send Executable Agreement (ISA) 15 days
Total Maximum Days 135/160 days (200 days for
Standard Complex)
Construction Schedule By Mutual Agreement
Witness Test 10 days or by mutual agreement
16
Summary and Recommendations
This is a high-level overview of the interconnection process. The interconnection tariff,
applicable rules, laws, regulations and MDPU orders set forth the interconnection
requirements. The customer must comply with all interconnection requirements.
Submit your interconnection application with National Grid early, during conception phase
before committing to buying no matter how simple or small the DG might be.
Large interconnection applications take longer to study
Proposed facilities ≥ 5MW must undergo ISO-NE Notification Process and
Transmission Study
Adjacent facilities with aggregate ≥ 5MW may also be considered for the ISO-NE
Notification Process and Transmission Study
Company processing time frames are standard working days (Business Days) and do not
include customer delays, including due to missing information, third party delays, or force
majeure events
http://www9.nationalgridus.com/masselectric/business/energyeff/distributed_generation.asp
17
Before considering any system design changes consult
your CEI project manager, including but not limited to:
Change in system size
Adding energy storage
Change in generator type
Change in inverters
Project Design Changes
18
Place your chosen
image here. The four
corners must just
cover the arrow tips.
For covers, the three
pictures should be the
same size and in a
straight line.
DG Updates Massachusetts
MA DG Penetration-
Connected & Proposed
Gardner/Westminster/Winchendon
214MW – spread over 4 substations
Leicester/Oxford/Worcester/Auburn
125MW – spread over 4 substations
Belchertown/Granby/North Palmer
208MW – spread over 3 substations
Barre/Ware/Hardwick
135MW – spread over 2 substations
Palmer/Warren/Monson
135MW – spread over 3 substations
N. Brookfield/Spencer
110MW – spread over 2 substations
Athol/Royalston/Wendell
147MW – spread over 3 substations
20
Total of 1.074GW on
this portion of the
system alone
Please Note: This information is provided as an aid to
project planning and will change as projects proceed
through the interconnection process.
MA High Penetration Map –
Connected and Pending
21
#’s refer to MW
Top 3 Connected and Pending Areas:
Belchertown – 137 MW
Winchendon – 92 MW
Warren – 81 MW
Please Note: The information in this MA High Penetration Heat Map is provided as an aid to project planning and will change
as projects proceed through the interconnection process.
Notes on High Penetration Map
22
Highlighted/referenced towns indicate that town all, or in
part, has high DG penetration based on area substation DG
applications
Map is not a guarantee of DG penetration levels in any town,
and does not imply any specific conclusions to be drawn for
requirements of a specific Impact Study
Map is provided here as a visual reference to convey the
general location of the Ngrid service territory that is seeing
generally high penetration levels
All values subject to change based on applications
entering/exiting the queue
Adding Energy Storage Pre-ISA
24
If adding an energy storage system after submitting your application, please start by
informing your National Grid job owner.
The following steps will then need to be taken for the application:
Pre-ISA (i.e. Screening, Supplemental Review, Impact Study)
National Grid considers the addition of AC and/or DC coupled storage to be a “significant”
change
Per Section 3.5 of the Interconnection Tariff: “the Interconnection Customer will be required to
submit a new Interconnection Application with associated fees and the revised project shall be
placed at the end of the project queue.”
The new Interconnection Application will require the following to be submitted
Updated one-line showing the addition of the ESS
Updated site plan showing the addition of the ESS
The ESS Operating Narrative (Section 4 of the “Supporting Documentation_DER_Islanding and
Fault Data Request.doc”)
The ESS Data Collection file (“ESS Data Collection_v9”)
Anti-Islanding letter for additional inverters (if applicable)
Adding Energy Storage Post-ISA
25
If adding an energy storage system after you have an executed ISA, please start by
informing your National Grid job owner.
The following steps will then need to be taken for the ESS:
The addition of AC and/or DC coupled storage will require the Customer to submit a new
and separate application for the ESS (Energy Storage System) with a new queue position
The executed ISA for the photovoltaic system remains in effect, including but not limited to the
payment terms, construction milestone schedule, effective date and queue position
The new Interconnection Application for the ESS will require the following to be submitted
in addition to all other standard application materials:
A new one-line showing the ESS with all other proposed/installed generators at the site
A new site plan showing the ESS with all other proposed/installed generators at the site
The ESS Operating Narrative (Section 4 of the “Supporting Documentation_DER_Islanding and
Fault Data Request.doc”)
The ESS Data Collection file (“ESS Data Collection_v9”)
Anti-Islanding letter for additional inverters (if applicable)
ESS FAQ
Why does my application have to be restudied if ESS is AC-coupled and
limited to the output previously studied?
Fundamentally different technology from original project
Control scheme evaluation
Equipment & operating schedule proposed
Protection Analyses
Added inverters affect fault current output
Load Flow Analyses
Generation no longer bounded by daytime hours
Any new site functionality (ramp rate control, advanced controls, etc)
26
ESS FAQ
Why does my application have to be restudied if ESS is DC-
coupled and we’re not adding additional inverters?
Fundamentally different technology from original project
Load Flow Analyses
Generation no longer bounded by daytime hours
Any new site functionality (ramp rate control, advanced
controls, etc)
27
29
Agenda
The Interconnection Process – What’s
changing, what won’t
Timeline
Roles of the Parties – DOER, EDC,
SPA interactions with program
participants and the parties
National Grid/Utilities Metering Drafts
Summary of Important Dates and Actions
30
Date(s) Action
October 11, 2018 - October 19, 2018
In person SMART transition stakeholder meetings held throughout Commonwealth
October 16, 2018 EDCs jointly file revised model tariff with DPU
October 24, 2018 SMART Statement of Qualification Application webinar
November 1, 2018 EDCs individually file SMART Factor cost recovery filings with DPU
November 26, 2018 SMART Application Launches at 12 PM ET / Final Eligibility Date for SREC II
November 30, 2018 Initial SMART application period ends at 11:59 PM ET
Approx. December 1, 2018 MLP solar rebate program opens and begins accepting applications
December 10, 2018 Documents demonstrating mechanical completion due for SREC II systems larger than 25 kW DC
February 15, 2019 SREC II applications systems equal to or smaller than 25 kW DC due
TBD DPU order approving revised joint model tariff
TBD EDCs file company specific SMART tariffs
TBD DPU approves company specific SMART tariffs
TBD DPU issues order on 17-146
31
The Interconnection Process
Things staying the same:
EDC specific processes and tools for
making, monitoring interconnection
requests
Interconnection timelines
EDC teams supporting the
interconnection process
The MA SMART / SPA incentive
application process is designed to
complement the EDC
interconnection process, not
replace it
32
The Interconnection Process
Things that will change:
Additional applicant-paid metering
charges
In behind the meter situations, need for
a second, utility installed meter for
measuring system output behind the
retail meter
Will require customer-installed wiring,
installation of a second meter socket
Must be adequately accessible, proximate
to existing utility revenue meter
33
Who you gonna call?
Issue type Primary point of contact
General MA SMART Program
questions
Program / adder eligibility
questions
Incentive application status
/ process questions
Interconnection application
status / process questions
Incentive rate calculation
questions
Incentive payment questions
34
Key Distinction
Behind-the-Meter Standalone
System that serves on-site
load other than parasitic or
station load utilized
to operate the unit
System that serves no
associated on-site load other
than parasitic or station load
utilized to operate the unit
Behind the meter systems will be compensated
differently than standalone systems
57
Contact Info
Gerald (Jed) Ferris
Smart Solar Program Manager
National Grid
401 784-7364 Work
401 450-9417 Cell
245 South Main Street, Hopedale, MA.
https://www.mass.gov/solar-massachusetts-renewable-
target-smart
ISO-NE PUBLIC
O C T O B E R 1 8 , 2 0 1 8
ISO New England A S S E T R E G I S T R A T I O N A N D N E W G E N E R A T I O N C O O R D I N A T I O N
Generators Defined in the Wholesale Market
ISO-NE Asset Registration
ISO-NE PUBLIC ISO-NE PUBLIC
FOREWORD Getting From Interconnection To Wholesale Market Integration
59
ISO-NE PUBLIC
Leg 1: Interconnection
• Non-FERC Jurisdictional – Local utility/State process – Interconnection studies – Two-party Interconnection Agreement – Wholesale market designation – TBD
• FERC Jurisdictional – ISO New England process – Interconnection studies – Three-party Interconnection Agreement – Wholesale market designation- Yes
60
Interconnection Request
Interconnection Studies
Interconnection Agreement
ISO-NE PUBLIC
Leg 2: Wholesale Market Integration
• Administered by ISO-NE – Energy (Day-Ahead, Real-Time; Locational Marginal Prices) – Day-Ahead and/or Real-Time Load Obligation – Day-Ahead and/or Real-Time Generation Obligation – Regulation (System clearing price) – Forward Capacity Market (Capacity Supply Obligation) – Forward Reserves (generation portfolio) – Black Start – Voltage and Reactive Control (VAR)
• Utility load (serving) obligation – Pool Resources – Request for Proposal (RFP)- load serving – Distributed Generation
61
Project Developer Financial
Obligations Interconnecting
Utility Financial
Obligations Wholesale Market
ISO-NE PUBLIC ISO-NE PUBLIC
SETTLEMENT ONLY GENERATOR (SOG) Simplified Registration Process and Wholesale Market Integration
62
ISO-NE PUBLIC
Settlement Only Generator
• ISO-NE Operating Procedure 14
• Asset Registration – Technical
• Less than 5 MW and interconnecting below 115 kV • Aggregation rules (case-by-case review)
– Market Participant (MP) Roles • Lead Market Participant- Asset • Lead Market Participant- Resource (Forward Capacity Market, if
applicable) • Market Participant Owner (wholesale settlement obligation)
– Energy Market
63
5 business days process
Interval Meter/60 kW
ISO-NE PUBLIC ISO-NE PUBLIC
MODELED/DEFINED GENERATOR New generation process and Wholesale Market Integration
64
ISO-NE PUBLIC
Modeled/Defined Generator
• Proposed Plan Application
• ISO-NE Operating Procedure 14
• ISO-NE Operating Procedure 18
• Asset Registration – Technical
• Interconnecting at 115 kV or greater • 5 MW or greater interconnecting at any kV level • Aggregation rules (case-by-case review) • eMarket schedule (must run or economic)
– Market Participant (MP) Roles • Lead Market Participant- Asset • Lead Market Participant- Resource (Forward Capacity Market, if applicable) • Market Participant Owner (wholesale settlement obligation)
– Project developer or interconnecting (host) utility or existing MP
– Energy Market, Forward Capacity Market, Regulation*, Forward Reserves*, Black Start*, VAR* (*as capable)
65
120 business days- Minimum
ISO-NE PUBLIC
Modeled/Defined Generator (Continued)
• New Generation Process – Dispatch Location (24/7/365 operational awareness) – Power System Model (February/May/September) – ISO-NE system integration (settlement and dispatch) – Data models (As-Studied, As-Purchased, As-Built) – Additional Information
66
Interconnection studies
Interconnection Agreement
New Generation Coordination
Proposed Plan Application
RC Approval
ISO-NE PUBLIC
Modeled/Defined Generator (Continued)
67
As-Studied data models
As-Purchased data models
As-Built data models
Dynamic Data Management System (DDMS)
Material Modification Risk
ISO-NE PUBLIC
What is ISO-NE OP14 and OP18?
• ISO-NE Operating Procedure 14 – Technical Requirements
• Reactive data • Transmission system data (as applicable) • Short Circuit data • Governor models • Protection systems • Other
• ISO-NE Operating Procedure 18 – Remote Terminal Unit (RTU)
• Directly Connected Front End- ISO-NE – Telemetry – Market data – Reliability data
68
ISO-NE PUBLIC
Appendix: Resources, Documents, Links Additional Information
• Maintain minute-to-minute reliable operation of region’s generation and transmission system
• Objective- perform centralized economic dispatch of the bulk power system
• Coordinate and schedule maintenance outages
• Coordinate operations with neighboring power systems
72
ISO-NE PUBLIC
Appendix: Resources, Documents, Links Additional Information
73
• New Generation Project Summary and Checklist – http://www.iso-ne.com/participate/applications-status-changes/asset-registration
• New Generator Projects: Process Guide – https://www.iso-ne.com/static-assets/documents/2016/08/new_generator_projects_process_guide.pdf
• ISO-NE Transmission, Markets, and Services Tariff – http://www.iso-ne.com/participate/rules-procedures/tariff
• New Customer Registration (2-4 month process) – http://www.iso-ne.com/participate/applications-status-changes/new-registration/registration-checklist
• ISO-NE Planning Procedures (PP05-0, PP05-1) – http://www.iso-ne.com/static-assets/documents/rules_proceds/isone_plan/pp05_0/pp5_0.pdf – http://www.iso-ne.com/static-assets/documents/rules_proceds/isone_plan/pp05_1/pp5_1.pdf
• ISO-NE Manuals – http://www.iso-ne.com/participate/rules-procedures/manuals
ISO-NE PUBLIC
Appendix: Resources, Documents, Links Additional Information
• ISO-NE Operating Procedures (OP1, 12, 14, 16, 18, 23) – http://www.iso-ne.com/participate/rules-procedures/operating-procedures – http://www.iso-ne.com/static-assets/documents/rules_proceds/operating/isone/op1/op1_rto_final.pdf – http://www.iso-ne.com/static-assets/documents/rules_proceds/operating/isone/op12/op12_rto_final.pdf – http://www.iso-ne.com/static-assets/documents/rules_proceds/operating/isone/op14/op14_rto_final.pdf – http://www.iso-ne.com/static-assets/documents/rules_proceds/operating/isone/op16/op16_rto_final.pdf
– http://www.iso-ne.com/static-assets/documents/rules_proceds/operating/isone/op18/op18_rto_final.pdf
– http://www.iso-ne.com/static-assets/documents/rules_proceds/operating/isone/op23/op23_rto_final.pdf
• Generator Asset Registration – http://www.iso-ne.com/participate/applications-status-changes/asset-registration
– http://www.iso-ne.com/static-assets/documents/2014/10/generator-asset-registration-options.pdf
• ISO-NE Training – http://www.iso-ne.com/participate/training
74
ISO-NE PUBLIC
Appendix: Resources, Documents, Links Additional Information
• ISO-NE Electronic Dispatch – Circuit and Router Order Form (if applicable) – Order at least 90+ days in advance of initial synchronization – Lead Market Participant coordinates with the ISO-NE New Generation Coordinator – Submit via Ask ISO – OR – – [email protected]
• Forward Capacity Market – http://www.iso-ne.com/markets-operations/markets/forward-capacity-market
• Transmission Service Applications (review with the interconnecting utility) – http://www.iso-ne.com/participate/applications-status-changes/transmission-service-applications
• Wind Integration Data Exchange Specification (Web services) – http://www.iso-ne.com/participate/support/user-guides
75
ISO-NE PUBLIC
Appendix: Resources, Documents, Links Additional Information
• Voltage and Reactive Control data submittal (ISO-NE OP12) – NX Application Training for NX12D Administrators
• http://www.iso-ne.com/static-assets/documents/support/training/courses/nx_application/nx12d_admin_11_12_2013.pdf
• Transmission System data submittal (ISO-NE OP16) – NX Application Training for NX9 Administrators
• http://www.iso-ne.com/static-assets/documents/2014/10/nx9admin_11_13_2013.pdf
• Generating Availability Data Systems (GADS) – Information Submittal Requirements
• https://www.iso-ne.com/system-planning/resource-planning/gads-reporting
• Contact – ISO-NE Asset Registration and Auditing (New Generation Coordinator)
– ISO-NE Customer Support • [email protected] • 413-540-4220 • Ask ISO (via the Standard Market Design portal)
76
ISO-NE PUBLIC
For More Information
Subscribe to the ISO Newswire ISO Newswire is your source for regular news about ISO New England and the wholesale electricity industry within the six-state region
77
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